Electricity as the new eggs: Affordability concerns will swing the midterms just like the 2024 election, Bill McKibben says

U.S. electricity prices have risen sharply since January 2025 (national average 15.94¢/kWh in Jan 2025 to 18.07¢/kWh in Sept and 17.98¢/kWh in Oct — a 12.8% increase in 10 months), with some states seeing increases three times the national rate, adding roughly $18/month at 900 kWh. Political and regulatory actions — including the Trump administration pausing major offshore wind projects and the expiration of federal clean-energy tax incentives on Dec. 31 — are raising policy risk and could shape voter sentiment ahead of elections, while global trends show falling wind and solar costs and China leading renewable and EV capacity (one Chinese EV firm recently outsold Tesla). For investors, the story highlights near-term upside pressure on consumer energy costs and political risk for U.S. energy policy, alongside longer-term structural tailwinds for renewables and distributed solar adoption.

Analysis

Market structure: Rising retail electricity (+12.8% YoY in 10 months) and political headwinds for federal renewables policy create a two-track market: incumbent fossil fuel producers (XOM, CVX) and regional thermal generators gain pricing power near-term while global panel/inverter manufacturers (FSLR, ENPH) retain longer-term cost advantages as LCOE for wind/solar continues falling. Mid-Atlantic capacity tightness implies localized merchant power spikes and higher spark spreads for gas-fired generators; regulated utilities (DUK) will seek rate relief and pass costs to consumers, supporting utility bond credit quality in the near term but pressuring customer growth.

Risk assessment: Tail risks include abrupt tariff/ban escalation on Chinese panels or wholesale permitting freezes that could raise capex +20–40% for US projects, and a Biden 2026 policy reversal restoring subsidies (binary political tail). Immediate catalysts (days–weeks) are grid operator directives and court rulings on offshore projects; medium term (3–12 months) risk centers on election-driven subsidies and tax-credit renewals; long term (2–5 years) technology cost declines and Chinese production scale continue to compress margins for US installers.

Trade implications: Favor selectively long equipment makers and short US installers dependent on subsidies: establish 2–3% longs in FSLR and 1–2% long ENPH, paired with 1–2% shorts in RUN and SPWR over 3–12 months. Buy 3–6 month call spreads on ENPH (protect cost) and sell near-term covered calls on utility ETF (XLU) to harvest yield while avoiding long-duration rate risk; add a 1–2% tactical long in Henry Hub (NG) futures if prompt-month >$3.50/MMBtu for winter-supply risks. Reduce long-duration Treasuries by 2–4% to hedge inflation risk from higher power prices.

Contrarian angles: Consensus treats federal hostility to renewables as terminal for the sector — that underestimates economics and state-level action. Plug-and-play panels and falling module costs mean distributed adoption can accelerate even without federal credits, benefiting inverter/microinverter makers (ENPH) more than installers (RUN). Historical parallels: subsidy cycles in Europe produced short-term installer distress but stronger global manufacturers; expect similar divergence here, creating mispricings for 6–24 month horizon.

Key Decisions for Investors

• Establish a 2–3% portfolio long in First Solar (FSLR) over 3–12 months to capture continued global demand and LCOE advantage; add to position if US electricity price index rises another 5–10% or if module ASPs fall >10%.
• Initiate a 1–2% long position in Enphase Energy (ENPH) and buy a 3–6 month call spread (e.g., strike ~10–15% OTM) to play rooftop & plug-in solar hardware adoption; trim on 25% realized gain or if installer sentiment improves materially.
• Open a 1–2% short position in Sunrun (RUN) and consider pair: long FSLR / short RUN to exploit manufacturer vs installer divergence; tighten stops if federal tax credits are reinstated within 60 days.
• Allocate 1–2% to short-duration Treasuries (sell 7–10yr exposure) and add 1% long in Henry Hub natural gas futures if prompt contract exceeds $3.50/MMBtu, as higher electricity prices imply upward pressure on gas demand and inflation.
• Harvest yield via a 2–4% covered-call write on a utility ETF (XLU) with 1–3 month expiries to generate income while waiting for regulatory clarity; exit if XLU falls >8% or if a major subsidy reversal is announced.